Method of and system for drilling information management and resource planning

ABSTRACT

In one aspect, the present invention relates to a drilling-information-management system. The drilling-information management system includes a probe assembly disposed on a drill rod, a first computer interoperably coupled to the probe assembly via a conductor disposed in a drill rod, and a second computer in communication with the first computer. The second computer includes a barcode scanner. The drilling-information management system includes a database in communication with the second computer. Drilling-project data is transferred from the database to the second computer and calibration data is transferred from the second computer to the first computer. The first computer executes a drilling plan according to the drilling-project data.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application is a continuation of U.S. patent application Ser. No.13/495,164, filed Jun. 13, 2012. U.S. patent application Ser. No.13/495,164 claims priority to U.S. Provisional Patent Application No.61/496,906, filed Jun. 14, 2011. U.S. patent application Ser. No.13/495,164 and U.S. Provisional Patent Application No. 61/496,906 areincorporated herein by reference.

BACKGROUND

1. Field of the Invention

The present invention relates to management systems for drillingprojects and more particularly, but not by way of limitation, to systemsfor managing information associated with an undergrounddirectional-drilling project including, for example, drilling plans,drilling data, material consumption, equipment wear, equipmentmaintenance, and project cost.

2. History of the Related Art

The practice of drilling non-vertical wells via directional drilling(sometimes referred to as “slant drilling”) has become very common inenergy and mining industries. Directional drilling exposes a largersection of a subterranean reservoir than vertical drilling, and allowsmultiple subterranean locations to be reached from a single drillinglocation thereby reducing costs associated with operating multipledrilling rigs. In addition, directional drilling often allows access tosubterranean formations where vertical access is difficult or impossiblesuch as, for example, formations located under a populated area orformations located under a body of water or other natural impediment.

Despite the many advantages of directional drilling, high costassociated with completing a well is often cited as the largestshortcoming of directional drilling. This is due to the fact thatdirectional drilling is often much slower than vertical drilling due torequisite data-acquisition steps. Thus, controlling and managing costsbecomes a chief concern during directional-drilling.

SUMMARY

The present invention relates to management systems for drillingprojects and more particularly, but not by way of limitation, to systemsfor managing information associated with an undergrounddirectional-drilling project including, for example, drilling plans,drilling data, material consumption, equipment wear, equipmentmaintenance, drilling performance, and project cost. In one aspect, thepresent invention relates to a method for executing adirectional-drilling project. The method includes storingdrilling-project data on a database, transferring the drilling-projectdata from the database to a second computer having a barcode scanner,and utilizing the barcode scanner to input equipment information to thesecond computer. The method further includes transferring calibrationdata from the second computer to a first computer, executing a drillingplan, via the first computer, according to the drilling-project data,and transferring survey information from a downhole probe assembly tothe first computer.

In another aspect, the present invention relates to a method of managinga drilling project. The method includes storing drilling-project data ona database, compiling, via the database, drilling-requirements data,transferring the drilling-requirements data to a drilling-managemententity, retrieving the drilling-project data from the database by asecond computer having a barcode scanner. The method further includesutilizing the barcode scanner to input equipment information into thesecond computer, transferring calibration data from the second computerto a first computer, and executing a drilling plan, via the firstcomputer, in accordance with the drilling-project data.

In another aspect, the present invention relates to adrilling-information-management system. The drilling-informationmanagement system includes a probe assembly disposed on a drill string,a first computer interoperably coupled to the probe assembly via aconductor disposed in a drill rod, and a second computer incommunication with the first computer. The second computer includes abarcode scanner. The drilling-information management system includes adatabase in communication with the second computer. Drilling-projectdata is transferred from the database to the second computer andcalibration data is transferred from the second computer to the firstcomputer. The first computer executes a drilling plan according to thedrilling-project data.

The foregoing has outlined some of the features and technical advantagesof the present invention in order that the detailed description of theinvention that follows may be better understood. Additional features andadvantages of the invention will be described hereinafter which form thesubject of the claims of the invention.

BRIEF DESCRIPTION OF THE DRAWINGS

For a more complete understanding of the present invention and forfurther objects and advantages thereof, reference may now be had to thefollowing description taken in conjunction with the accompanyingdrawings in which:

FIG. 1A is a schematic diagram of a drilling-information-managementsystem according to an exemplary embodiment;

FIG. 1B is a schematic diagram of a drilling-information-managementsystem utilizing a computer according to an exemplary embodiment;

FIG. 1C is a schematic diagram of a drilling-information-managementsystem utilizing a memory device according to an exemplary embodiment;

FIG. 2 is a cross-sectional view of a drill rod according to anexemplary embodiment;

FIG. 3 is a flow diagram of a process for planning adirectional-drilling project according to an exemplary embodiment;

FIG. 4A is a flow diagram of a drilling-data-analysis process accordingto an exemplary embodiment;

FIG. 4B is a flow diagram of a drilling-data-analysis process utilizinga memory device according to an exemplary embodiment; and

FIG. 5 is a flow diagram of a drilling-forecasting process according toan exemplary embodiment.

DETAILED DESCRIPTION

Various embodiments of the present invention will now be described morefully with reference to the accompanying drawings. The invention may,however, be embodied in many different forms and should not be construedas limited to the embodiments set forth herein.

During a directional-drilling project, a drill operator is provided awell path that is predetermined by engineers and geologists prior todrilling. When the directional-drilling project is started, frequentsurveys are taken with downhole instruments to provide survey dataincluding, for example, pitch and azimuth, of a well bore. As usedherein, the term “pitch” refers to an angular measurement of deviationof the well bore relative to a vertical plane. As used herein, the term“azimuth” refers to an angle of the well bore as projected onto ahorizontal plane relative to due north. In some cases, tools such as,for example, a measurement-while-drilling tool (“MWD”) and alogging-while-drilling (“LWD”) tool are added to a drill string toprovide continuous updated measurement allowing for real-time ornear-real-time monitoring and adjustments.

FIG. 1A is a schematic diagram of a drilling-information-managementsystem according to an exemplary embodiment. Adrilling-information-management system 100 includes a probe assembly 102coupled to a drill rod 118. The probe assembly 102 communicates with afirst computer 106. The drilling-information-management system 100 alsoincludes a second computer 108 interoperably coupled to the firstcomputer 106, and a database 110 interoperably coupled to the secondcomputer 108. The probe assembly 102 includes a battery pack 111 and aplurality of drilling-data-acquisition instruments such as, for example,a directional sensor 113 having, for example, a tri-axial magnetometerand a tri-axial accelerometer and a focused gamma sensor 115. In atypical embodiment, the directional sensor 113 is accurate toapproximately 0.1 degrees of inclination and approximately 0.3 degreesazimuth. In a typical embodiment, the focused gamma sensor 115 isaccurate to within approximately 5%. In a typical embodiment, the probeassembly 102 is contained in an explosion-proof pressure barrel 114constructed of a material such as, for example, a copper-beryllium alloyor other non-magnetic alloy. The probe assembly 102 is mounted onto thedrill rod 118 via a plurality of shock absorbers and lugs (notexplicitly shown). In a typical embodiment, the drill rod 118 is coupledto an adjacent drill rod (not explicitly shown) to form a drill string116.

Referring still to FIG. 1A, the first computer 106 is, for example, anuphole computer. The first computer 106 includes a user interface 119such as, for example, a touch screen. In a typical embodiment, the firstcomputer 106 is contained in an explosion-proof housing suitable for usein a variety of drilling environments such as, for example, drilling ina potentially explosive atmosphere. The first computer 106 includes atouch-screen key pad 121 enabling a user to record data such as, forexample, a length of the drill string 116 and a position of the drillstring 116. In a typical embodiment, the first computer 106 is capableof operating within a temperature range between approximately −20° C.and approximately 45° C. The first computer 106 includes a real-timeclock with graphic capabilities. During operation, the first computer106 is capable of real-time monitoring of actual drilling against aplanned hole design. The first computer 106 calculates a position of aborehole based on, for example, pitch, azimuth, and depth. In otherembodiments, the first computer 106 may be connected to a plurality oftransducers disposed, for example, on the probe assembly 102. The firstcomputer 106 may monitor the plurality of transducers during drilling toobtain measurements of, for example, thrust pressure, water flow, androtational speed. The first computer 106, via the user interface 119,displays a drilling plan and profile plot, perform tool calibrations,and may display measurements such as, for example, gamma count and gammatool face as a function of drilling depth. In addition, the firstcomputer 106 may also display environmental data such as, for example,temperature and vibration. In a typical embodiment, the first computer106 is capable of supporting multiple languages such as, for example,Mandarin, Russian, and English.

Still referring to FIG. 1A, in a typical embodiment, the second computer108 is contained in an explosion-proof housing. The second computer 108is, for example, a hand-held device; however, one skilled in the artwill recognize that any appropriate data-transfer device could beutilized. The second computer 108 includes a real-time clock havinggraphic capabilities and is capable of transferring data to, andreceiving data from, the first computer 106 and the database 110 via awireless protocol such as, for example, a wireless local-area-networksuch as, for example, Wi-Fi®, or a personal-area-network such as, forexample, Bluetooth®. In various alternative embodiments, however, thesecond computer 108 may communicate with the first computer 106 and thedatabase 110 via a wired connection (not explicitly shown). Duringoperation, the second computer 108 calibrates the probe assembly 102. Ina typical embodiment, the probe assembly 102 derives an azimuth based onthe Earth's magnetic field, commonly referred to as a “magneticazimuth.” Calibration determines a difference between the magneticazimuth and an azimuth derived from a mine survey grid, commonlyreferred to as a “grid azimuth.” Calibration is performed by orientingthe probe assembly 102 along the grid azimuth and comparing the magneticazimuth, as determined by the probe assembly 102, with the grid azimuth,as determined by a surveyor. During calibration, the probe assembly isrotated along a longitudinal axis to obtain a plurality of data points.Several calibrations may be performed at various grid azimuths.

Still referring to FIG. 1A, the second computer 108 is capable ofdisplaying drilling data in plan and profile views via a display 123. Ina typical embodiment, the second computer 108 is capable of supportingmultiple languages such as, for example, Mandarin, Russian, and English.The first computer 106 and the second computer 108 have been describedby way of example as separate devices; however, in various alternativeembodiments, the first computer 106 and the second computer 108 may becombined in a single device such as, for example, a single computer.

Still referring to FIG. 1A, the second computer 108 includes a bar-codescanner 120 for receiving equipment information 352 (shown in FIG. 3)related to the drilling process. The equipment information 352 mayinclude, for example, an identification of parts and equipment used inthe drilling process, an identification of consumables used duringdrilling, and a quantity of consumables used during drilling. Oneskilled in the art will recognize that, in various alternativeembodiments, the second computer 108 may receive the equipmentinformation 352 via any appropriate device such as, for example, a QuickResponse (“QR”) code reader or an RFID receiver. During drilling, thesecond computer 108 collects project parameters such as, for example,duration of service of equipment, activities undertaken during a shift,and notification of equipment or drilling issues that arise. In atypical embodiment, the second computer 108 records notifications ofequipment and drilling issues via, for example, voice recording orphotograph. Although the first computer 106 and the second computer 108are described in FIG. 1A is being independent devices; one skilled inthe art will recognize that, in other embodiments, the first computer106 and the second computer 108 may be combined in a single device suchas, for example, a single computer.

Still referring to FIG. 1A, in a typical embodiment, the database 110 isa virtual-management database; however, one skilled in the art willrecognize that, in various alternative embodiments, any appropriatedatabase could be utilized such as, for example, SQL, ODBC, and thelike. During operation, the database 110 compiles information receivedfrom the second computer 108 and generates, for example, as-drilledplots, daily invoices for services, charges versus budget comparison,estimated time to completion and project charges, project keyperformance indicators, consumable orders, part orders, inventoryorders, rebuild schedules, and safety and risk-management information.In various embodiments, the database 110 stores inventory informationrelated to the drilling process. In a typical embodiment, the database110 generates plots of information received from the second computer 108including, for example, borehole orientation relative to plan, gammapolygon, inventory levels, equipment use time, and time-managementdiagrams. The database 110 is installed on, for example, a remote serverwith multiple users; however, in various alternative embodiments, thedatabase 110 may be installed on a standalone computer. In a typicalembodiment, the database 110 is capable of supporting multiple languagessuch as, for example, Mandarin, Russian, and English. During operation,a supplier of the drilling-information-management system 100 may accessinformation stored on the database 110. The supplier may assist a userof the drilling-information-management system 100 with, for example,diagnostics, borehole design, drilling problems, and equipment problems.In addition, the supplier may send reminders regarding, for example,servicing of the drilling-information-management system 100 andconsumables needs.

FIG. 1B is a schematic diagram of a drilling-information-managementsystem utilizing a third computer according to an exemplary embodiment.In situations where communication between the second computer 108 andthe database 110 is not possible, a third computer 152 is utilized. In atypical embodiment, the third computer 152 is a stand alonedatabase-management system that does not require an internet connection.A local database is installed on the third computer 152. During periodsof time where communication between the third computer 152 and thedatabase 110 is possible, the third computer 152 syncs with the database110. In a typical embodiment, the third computer 152 communicates withthe database via a wireless protocol such as, for example, a wirelesslocal-area-network such as, for example, Wi-Fi®, or apersonal-area-network such as, for example, Bluetooth®. In a typicalembodiment, the third computer 152 is capable of supporting multiplelanguages such as, for example, Mandarin, Russian, and English. Duringoperation, the third computer 152 compiles information received from thesecond computer 108 and generates, for example, as-drilled plots, dailyinvoices for services, charges versus budget comparison, estimated timeto completion and project charges, project key performance indicators,consumable orders, part orders, inventory orders, rebuild schedules, andsafety and risk-management information. In various alternativeembodiments, the third computer 152 may also store inventory informationrelated to the drilling process.

FIG. 1C is a schematic diagram of a drilling-information-managementsystem utilizing a memory device according to an exemplary embodiment.In situations where communication between the second computer 108, thedatabase 110, or the third computer 152 is not possible, a memory device154 coupled to the first computer 106 is utilized. In a typicalembodiment, the memory device 154 may be a non-volatile memory devicesuch as, for example, a universal serial bus (USB) flash device, asecure digital (SD) card, a compact flash (CF) card, or any otherappropriate memory device. During operation, the memory device 154receives and stores drilling information from the first computer 106.The memory device is manually disconnected from the first computer 106and coupled to the third computer 152. Drilling information stored onthe memory device 154 is then transferred to the third computer 152. Inother embodiments, the memory device is coupled to the database 110instead of the third computer 152.

FIG. 2 is a cross-sectional view of the drill rod 118 according to anexemplary embodiment. The drill rod 118 includes a conductor 202 that isarranged coaxially within the drill rod 118. In a typical embodiment,the conductor 202 is disposed such that an insulated electricalconnection is established when, for example, the drill rod 118 iscoupled to the adjacent drill rod (not explicitly shown). The conductor202 is secured laterally within the drill rod 118 by centralizers 204.The centralizers 204 are held in place by at least one groove 206 cutinto an inner diameter of the drill rod 118 at each end of the drill rod118. A fitting 208 having an O-ring 210 is disposed at each end of thedrill rod 118. The fitting 208 creates a substantially water-tightconnection between the drill rod 118 and adjacent equipment such as, forexample, the probe assembly 102 (shown in FIG. 1A), or the adjacentdrill rod (not explicitly shown). In a typical embodiment, the conductor202 is safe for use in gaseous and potentially explosive environments.

Referring now to FIG. 3, there is shown a flow diagram of a process forplanning a directional-drilling project according to an exemplaryembodiment. A process 300 begins at step 302. At step 304,drilling-project data is transferred to, and stored on, the database110. The drilling-project data includes, for example, borehole plans,project information, tool-calibration information, special instructions,inventory levels, consumables shipped, and software and manual updates.At step 306, the drilling-project data is retrieved from the database110 by an on-site drilling operator and transferred to the secondcomputer 108. At step 308, the on-site drilling operator transferscalibration data from the second computer 108 to the first computer 106.In a typical embodiment, the calibration data includes data pointscollected during the calibration process described above with respect toFIG. 1A. At step 310, the on-site drilling operator utilizes the barcodescanner 120 to input equipment information into the second computer 108.At step 312, the on-site drilling operator uses the first computer 106to execute the drilling plan in accordance with the drilling-projectdata. Although step 312 is described in FIG. 3 as occurring after step310, one skilled in the art will recognize that step 310 may beperformed concurrently with, or after, step 312. Further, as illustratedin FIG. 3, step 310 may be repeated during the performance of step 312.At step 314, the first computer 106 provides a request signal to theprobe assembly 102. The request signal activates the battery pack 111(shown in FIG. 1A) within the probe assembly 102. At step 316, the probeassembly 102 transfers survey information to the first computer 106 forprocessing. The survey information includes, for example, a boreholename, a shot number, an amount of left-right deviation, an amount ofup-down deviation, azimuth, pitch, date, time, and readings for shockand vibration as a function of hole depth.

Still referring to FIG. 3, the survey information may also include agamma-polygon plot, which is a graphical representation of focused gammareadings a particular horizontal survey depth. A gamma-polygon plot is apolar plot of natural background gamma radiation as a radial coordinateand the gamma tool face as an angular coordinate. Background gammaradiation is typically measured in counts per second (CPS). A magnitudeof a gamma reading at a particular gamma tool face is an indication of atype of rock being drilled and the proximity of the drill string 116 toa shale or other gamma-emitting strata. In a typical embodiment, aseries of gamma-polygon plots are generated at various survey depths.The series of gamma-polygon plots allows a user to determine, based ondifferences in CPS, relative placement within a coal seam. At step 318,when the survey information has been transferred to the first computer106, the battery pack 111 is de-activated and drilling commences. Theprocess 300 ends at step 320.

Referring now to FIG. 4A, there is shown a flow diagram of adrilling-data-analysis process according to an exemplary embodiment. Adrilling-data-analysis process 400 begins at step 402. At step 404, theprobe assembly 102 acquires drilling data including, for example,directional data, geophysical data, and environmental data. Thedirectional data may include, for example, at least one of a toolazimuth, a tool pitch, and a tool orientation. The environmental datamay include, for example, at least one of a downhole temperature, adownhole magnetic field, a magnetic field dip, and a measure ofvibration. The geophysical data may include, for example, data relatedto geophysical properties such as, for example, a gamma count, and agamma tool face.

Still referring to FIG. 4A, at step 406, the drilling data istransferred to the first computer 106 via the conductor 202 disposed inthe drill rod 118. At step 408, the drilling data is displayed by thefirst computer 106 via the user interface 119. The first computer 106may provide the drilling data collected from the probe assembly 102 intabular and graphical format including, for example, a drilling progressplot, drill-to-plan information, a downhole temperature, downholegeophysical data, and a gamma-polygon plot.

Still referring to FIG. 4A, at step 410, the drilling data is retrievedby the on-site drilling operator (not explicitly shown) and transferredto the second computer 108. At step 412, the second computer 108collects consumption data including, for example, a quantity ofconsumables used, parts used, drilling activities, and materialsrequired. At step 414, the second computer 108 utilizes the consumptiondata to generate operational data related to the drilling processincluding, for example, an equipment operational time (also known as“green-light time”), a delay period length, a cause of delay periods,component wear, and equipment use times to derive maintenance needs. Atstep 416, the drilling data, the consumption data, and the operationaldata are displayed by the second computer 108 via the display 123.

Still referring to FIG. 4A, at step 418 the second computer 108transfers the drilling data, the consumption data, and the operationaldata to the database 110. As shown in FIG. 1B, in various embodiments,the drilling data and the consumption data may be transferred to thedatabase 110 via the third computer 152. At step 420, the database 110utilizes the drilling data, the consumption data, and the operationaldata to generate management data. In a typical embodiment, themanagement data may include, for example, ordering information forequipment and consumables, delivery information for equipment andconsumables, customer-invoicing information, and performance-to-budgetinformation. At step 422, a drilling-management entity retrieves themanagement data from the database 110. The process 400 ends at step 424.

FIG. 4B is a flow diagram of a drilling-data-analysis process utilizinga memory device according to an exemplary embodiment. Adrilling-data-analysis process 450 begins at step 452. At step 454, theprobe assembly 102 acquires the drilling data including, for example,the directional data, the geophysical data, and the environmental data.At step 456, the drilling data is transferred to the first computer 106via the conductor 202 disposed in the drill pipe 118. At step 458, thedrilling data is displayed by the first computer 106 via the userinterface 119. The first computer 106 may provide the drilling datacollected from the probe assembly 102 in tabular and graphical formatincluding, for example, a drilling progress plot, drill-to-planinformation, a downhole temperature, downhole geophysical data, and agamma-polygon plot.

Still referring to FIG. 4B, at step 460, the drilling data is stored, bythe first computer 106, on the memory device 154. At step 462, thememory device 154 is removed from the first computer 106 and transferredto the third computer 152. At step 464, the drilling data is transferredfrom the memory device 154 to the third computer 152. At step 466, thethird computer 152 uses the drilling data to generate consumption dataincluding, for example, a quantity of consumables used, parts used,drilling activities, and materials required. At step 468, the thirdcomputer 152 utilizes the consumption data to generate operational datarelated to the drilling process including, for example, an equipmentoperational time (also known as “green-light time”), a delay periodlength, a cause of delay periods, component wear, and equipmentmaintenance needs. At step 470, the drilling data, the consumption data,and the operational data may be displayed by the third computer 152.

Still referring to FIG. 4B, at step 472 the third computer 152 transfersthe drilling data, the consumption data, and the operational data to thedatabase 110 when communication between the third computer 152 and thedatabase 110 is possible. At step 474 the database 110 utilizes thedrilling data, the consumption data, and the operational data togenerate management data. In a typical embodiment, the management dataincludes, for example, ordering information for equipment andconsumables, delivery information for equipment and consumables,customer-invoicing information, and performance-to-budget information.At step 476, the drilling-management entity retrieves the managementdata from the database 110. The process 450 ends at step 478.

FIG. 5 is a flow diagram of a drilling-forecasting process according toan exemplary embodiment. A drilling-data-analysis process 500 begins atstep 502. At step 504, drilling-project data is transferred to, andstored on, the database 110. At step 506, the database 110 compilesdrilling-requirements data and delivers the drilling-requirements datato a drilling-management entity. The drilling-requirements dataincludes, for example, equipment requirement forecasts, consumablerequirement forecasts, projected project budget, projected time tocompletion, current inventory levels, and ordering needs.

Still referring to FIG. 5, at step 508, the drilling-project data isretrieved from the database 110 by an on-site drilling operator (notexplicitly shown) and transferred to the second computer 108. At step510, the on-site drilling operator utilizes the barcode scanner 120 toinput equipment information into the second computer 108. At step 512,the on-site drilling operator transfers calibration data from the secondcomputer 108 to the first computer 106. In a typical embodiment, thecalibration data includes data points collected during the calibrationprocess described above with respect to FIG. 1A. By way of example, step510 is described herein as being performed prior to step 512; however,in various alternative embodiments, step 510 and step 512 may beperformed in any order. At step 514, the on-site drilling operator usesthe first computer 106 to execute the drilling plan in accordance withthe drilling-project data. At step 516, the first computer 106 providesa request signal to the probe assembly 102. The request signal activatesthe battery pack 111 (shown in FIG. 1A) within the probe assembly 102.At step 518, the probe assembly 102 obtains drilling data from adrilling environment. In a typical embodiment, the drilling dataincludes, for example, directional data, geophysical data, andenvironmental data. The directional data includes, for example, at leastone of a tool azimuth, a tool pitch, and a tool orientation. Theenvironmental data includes, for example, at least one of a downholetemperature, a downhole magnetic field, a magnetic field dip, and ameasure of vibration. The geophysical data may include data related togeophysical properties such as, for example, a gamma count and a gammatool face.

Still referring to FIG. 5, at step 520, the drilling data is transferredto the first computer 106 via conductor 202 disposed in the drill pipe118. At step 522, the drilling data is displayed by the first computer106 via the user interface 119. The first computer 106 provides thedrilling data collected from the probe assembly 102 in, for example,tabular and graphical format including, for example, drilling progressplots, drill-to-plan information, downhole temperature, and downholegeophysical data. At step 524, the drilling data is retrieved by theon-site drilling operator (not explicitly shown) and transferred to thesecond computer 108. At step 526, the second computer 108 collects, viathe barcode scanner 120, consumption data including, for example, aquantity of consumables used, parts used, drilling activities, andmaterials required. At step 528, the second computer 108 utilizes theconsumption data to generate operational data related to the drillingprocess including, for example, an equipment operational time (alsoknown as “green-light time”), a delay period length, a cause of delayperiods, component wear, and equipment maintenance needs. At step 530,the drilling data, the consumption data, and the operational data aredisplayed by the second computer 108 via the display 123.

Still referring to FIG. 5, at step 532 the second computer 108 transfersthe drilling data, the consumption data, and the operational data to thedatabase 110. As shown in FIG. 1B, in various embodiments, the drillingdata, the consumption data, and the operational data may be transferredto the database 110 via the third computer 152. At step 534, thedatabase 110 utilizes the drilling data, the consumption data, and theoperational data to generate management data. The management dataincludes, for example, ordering information for equipment andconsumables, delivery information for equipment and consumables,customer-invoicing information, and performance-to-budget information.At step 536, the database 110 reconciles the drilling data and theconsumption data with the drilling-requirements data to generateoperational-variance data. The operational-variance data includes, forexample, cost variance relative to budget, consumable variance relativeto forecasted requirements, and duration variance relative to forecastedcompletion time. At step 538, the drilling-management entity retrievesthe management data and the operational-variance data from the database110. The process 500 ends at step 540.

Although various embodiments of the method and system of the presentinvention have been illustrated in the accompanying Drawings anddescribed in the foregoing Specification, it will be understood that theinvention is not limited to the embodiments disclosed, but is capable ofnumerous rearrangements, modifications, and substitutions withoutdeparting from the spirit and scope of the invention as set forthherein. It is intended that the Specification and examples be consideredas illustrative only.

What is claimed is:
 1. A method for executing a directional-drillingproject, the method comprising: storing, on a database, drilling-projectdata; transferring, to a second computer, the drilling-project data;uploading, to the second computer, equipment information; determining,via the second computer, calibration data, the calibration datacomprising a difference between a magnetic azimuth and a grid azimuth;transferring, from the second computer to a first computer, thecalibration data; executing, via the first computer, thedirectional-drilling project; recording, via the second computer,parameters related to the directional-drilling project, the parameterscomprising at least one of consumables used, equipment service time,activities during a shift, a notification of equipment problems, and anotification of drilling problems; and utilizing the parameters todetermine at least one of diagnostic information, borehole designassistance, drilling problem assistance, and equipment problemassistance.
 2. The method of claim 1, wherein the survey informationincludes at least one plot of focused gamma readings at a horizontalsurvey depth.
 3. The method of claim 2, comprising utilizing the atleast one plot to determine relative placement within a coal seam. 4.The method of claim 1, wherein the drilling-project data comprises atleast one of a borehole plan, tool-calibration information, inventorylevels, and software updates.
 5. The method of claim 1, wherein thesurvey information comprises at least one of a borehole name, a shotnumber, an amount of left-right deviation, an amount of up-downdeviation, a tool azimuth, a tool pitch, a gamma-polygon plot, and ameasurement of shock and vibration as a function of depth.
 6. The methodof claim 1, further comprising transferring, from a probe assembly tothe first computer, survey information.
 7. A method of managing adrilling project, the method comprising: storing, on a database,drilling-project data; compiling, via the database,drilling-requirements data; transferring, to a drilling-managemententity, the drilling-requirements data; transferring thedrilling-project data to a second computer; uploading, to the secondcomputer, equipment information; determining, via the second computer,calibration data, the calibration data comprising a difference between amagnetic azimuth and a grid azimuth; transferring the calibration datafrom the second computer to a first computer; executing, via the firstcomputer, a drilling plan utilizing the drilling-project data;recording, via the second computer, parameters related to thedirectional-drilling project, the parameters comprising at least one ofconsumables used, equipment service time, a list of activities performedduring a shift, a notification of equipment problems, and a notificationof drilling problems; and utilizing the parameters to determine at leastone of diagnostic information, borehole design assistance, drillingproblem assistance, and equipment problem assistance.
 8. The method ofclaim 7, wherein the drilling-requirements data comprises at least oneof an equipment requirements forecast, a consumables requirementsforecast, a projected project budget, a projected time to completion, acurrent inventory level, and ordering needs.
 9. The method of claim 7,further comprising: Sending, from the first computer to a probeassembly, a request to collect drilling data; acquiring, via the probeassembly, the drilling data; transferring the drilling data from theprobe assembly to the first computer; retrieving, via the secondcomputer, the drilling data from the first computer; generating, via thesecond computer, at least one of consumption data and operational datafrom the drilling data; and transferring at least one of the drillingdata, the consumption data, and the operational data to the database.10. The method of claim 9, further comprising utilizing at least one ofthe drilling data, the consumption data, and the operational data togenerate at least one of management data and operational-variance data.11. The method of claim 10, wherein the management data comprises atleast one of equipment ordering information, consumable orderinginformation, equipment delivery information, consumable deliveryinformation, customer-invoicing information, and performance-to-budgetinformation.
 12. The method of claim 10, wherein theoperational-variance data comprises at least one of cost variancerelative to budget, consumable variance relative to forecastedrequirements, and project duration variance relative to forecastedcompletion time.
 13. The method of claim 9, wherein the drilling datacomprises at least one of geophysical data, directional data, andenvironmental data.
 14. The method of claim 13, wherein: the geophysicaldata comprises at least one of gamma count and gamma tool face; thedirectional data comprises at least one of a tool azimuth, a tool pitch,and a tool orientation; and the environmental data comprises at leastone of a downhole temperature, a downhole magnetic field, a magneticfield dip, and a measurement of downhole vibration.
 15. The method ofclaim 14, comprising utilizing the geophysical data to create at leastone plot of focused gamma readings at a horizontal survey depth.
 16. Themethod of claim 15, comprising utilizing the at least one plot todetermine relative placement within a coal seam.
 17. The method of claim9, further comprising displaying the drilling data.
 18. The method ofclaim 9, wherein the consumption data comprises at least one of aquantity of consumables used, a list of parts used, a list of drillingactivities, and a list of materials required.
 19. The method of claim 9,wherein the operational data comprises at least one of an equipmentoperational time, a delay period length, component wear, and equipmentmaintenance needs.
 20. A drilling-information-management systemcomprising: a probe assembly disposed on a drill string; a firstcomputer interoperably coupled to the probe assembly via the drillstring, the drill string comprising a drill rod; a conductor disposedwithin the drill rod, wherein electrical signals are transmitted betweenthe probe assembly and the first computer via the conductor; a secondcomputer in communication with the first computer, the second computercomprising a barcode scanner and operable to store calibration data,wherein calibration data is transferred from the second computer to thefirst computer; a database interoperably coupled with the secondcomputer, wherein drilling-project data is transferred from the databaseto the second computer; and wherein the first computer executes adrilling plan according to the drilling-project data.